CA2952398C - Analyzing oil sand streams - Google Patents
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- CA2952398C CA2952398C CA2952398A CA2952398A CA2952398C CA 2952398 C CA2952398 C CA 2952398C CA 2952398 A CA2952398 A CA 2952398A CA 2952398 A CA2952398 A CA 2952398A CA 2952398 C CA2952398 C CA 2952398C
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- 239000002002 slurry Substances 0.000 claims abstract description 94
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- 239000012530 fluid Substances 0.000 claims abstract description 29
- 238000012545 processing Methods 0.000 claims abstract description 14
- 239000002904 solvent Substances 0.000 claims description 24
- 238000005188 flotation Methods 0.000 claims description 13
- 239000002562 thickening agent Substances 0.000 claims description 10
- 239000004576 sand Substances 0.000 claims description 9
- 238000000926 separation method Methods 0.000 claims description 7
- ZLMJMSJWJFRBEC-OUBTZVSYSA-N potassium-40 Chemical compound [40K] ZLMJMSJWJFRBEC-OUBTZVSYSA-N 0.000 claims description 6
- ZSLUVFAKFWKJRC-UHFFFAOYSA-N thorium Chemical compound [Th] ZSLUVFAKFWKJRC-UHFFFAOYSA-N 0.000 claims description 6
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- 239000003518 caustics Substances 0.000 description 1
- 238000005119 centrifugation Methods 0.000 description 1
- 239000011362 coarse particle Substances 0.000 description 1
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- 125000004122 cyclic group Chemical group 0.000 description 1
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Classifications
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N23/00—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00
- G01N23/22—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by measuring secondary emission from the material
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V5/00—Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity
- G01V5/04—Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging
- G01V5/06—Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging for detecting naturally radioactive minerals
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N2223/00—Investigating materials by wave or particle radiation
- G01N2223/07—Investigating materials by wave or particle radiation secondary emission
- G01N2223/074—Investigating materials by wave or particle radiation secondary emission activation analysis
- G01N2223/0745—Investigating materials by wave or particle radiation secondary emission activation analysis neutron-gamma activation analysis
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N2223/00—Investigating materials by wave or particle radiation
- G01N2223/07—Investigating materials by wave or particle radiation secondary emission
- G01N2223/076—X-ray fluorescence
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N2223/00—Investigating materials by wave or particle radiation
- G01N2223/60—Specific applications or type of materials
- G01N2223/635—Specific applications or type of materials fluids, granulates
Abstract
Disclosed is a method comprising providing a slurry stream comprising bitumen, water, and solids; measuring a natural radiation parameter of the slurry stream; based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream, and based on the estimated FFR, automatically adjusting a process parameter of an oil sand processing plant.
Description
ANALYZING OIL SAND STREAMS
BACKGROUND
Field of Disclosure [0001] The disclosure relates generally to the field of oil sand processing.
Description of Related Art
BACKGROUND
Field of Disclosure [0001] The disclosure relates generally to the field of oil sand processing.
Description of Related Art
[0002] This section is intended to introduce various aspects of the art, which may be associated with the present disclosure. This discussion is believed to assist in providing a framework to facilitate a better understanding of particular aspects of the present disclosure.
Accordingly, it should be understood that this section should be read in this light, and not necessarily as admissions of prior art.
Accordingly, it should be understood that this section should be read in this light, and not necessarily as admissions of prior art.
[0003] Modern society is greatly dependent on the use of hydrocarbon resources for fuels and chemical feedstocks. Hydrocarbons are generally found in subsurface formations that can be termed "reservoirs". Removing hydrocarbons from the reservoirs depends on numerous physical properties of the subsurface formations, such as the permeability of the rock containing the hydrocarbons, the ability of the hydrocarbons to flow through the subsurface formations, and the proportion of hydrocarbons present, among other things. Easily harvested sources of hydrocarbons are dwindling, leaving less accessible sources to satisfy future energy needs. As the costs of hydrocarbons increase, the less accessible sources become more economically attractive.
[0004] Recently, the harvesting of oil sand to remove heavy oil has become more economical. Hydrocarbon removal from oil sand may be performed by several techniques. For example, a well can be drilled to an oil sand reservoir and steam, hot air, solvents, or a combination thereof, can be injected to release the hydrocarbons. The released hydrocarbons may be collected by wells and brought to the surface. In another technique, strip or surface mining may be performed to access the oil sand, which can be treated with water, steam or solvents to extract the heavy oil.
[0005] Oil sand extraction processes are used to liberate and separate bitumen from oil sand so that the bitumen can be further processed to produce synthetic crude oil or mixed with diluent to form "dilbit" and be transported to a refinery plant. Numerous oil sand extraction processes have been developed and commercialized, many of which involve the use of water as a processing medium. Where the oil sand is treated with water, the technique may be referred to as water-based extraction (WBE). WBE is a commonly used process to extract bitumen from mined oil sand. Other processes are non-aqueous solvent-based processes. An example of a solvent-based process is described in Canadian Patent Application No.
2,724,806 (Adeyinka et al, published June 30, 2011 and entitled "Process and Systems for Solvent Extraction of Bitumen from Oil Sands"). Solvent may be used in both aqueous and non-aqueous processes.
2,724,806 (Adeyinka et al, published June 30, 2011 and entitled "Process and Systems for Solvent Extraction of Bitumen from Oil Sands"). Solvent may be used in both aqueous and non-aqueous processes.
[0006] One WBE process is the Clark hot water extraction process (the "Clark Process").
This process typically requires that mined oil sand be conditioned for extraction by being crushed to a desired lump size and then combined with hot water and perhaps other agents to form a conditioned slurry of water and crushed oil sand. In the Clark Process, an amount of sodium hydroxide (caustic) may be added to the slurry to increase the slurry pH, which enhances the liberation and separation of bitumen from the oil sand. Other WBE
processes may use other temperatures and may include other conditioning agents, which are added to the oil sand slurry, or may operate without conditioning agents. This slurry is first processed in a Primary Separation Cell (PSC), also known as a Primary Separation Vessel (PSV), to extract the bitumen from the slurry.
This process typically requires that mined oil sand be conditioned for extraction by being crushed to a desired lump size and then combined with hot water and perhaps other agents to form a conditioned slurry of water and crushed oil sand. In the Clark Process, an amount of sodium hydroxide (caustic) may be added to the slurry to increase the slurry pH, which enhances the liberation and separation of bitumen from the oil sand. Other WBE
processes may use other temperatures and may include other conditioning agents, which are added to the oil sand slurry, or may operate without conditioning agents. This slurry is first processed in a Primary Separation Cell (PSC), also known as a Primary Separation Vessel (PSV), to extract the bitumen from the slurry.
[0007] In one bitumen extraction process, a water and oil sand slurry is separated into three major streams in the PSC: bitumen froth, middlings, and a PSC underflow (also referred to as coarse sand tailings (CST)).
[0008] Regardless of the type of WBE process employed, the process will typically result in the production of a bitumen froth that requires treatment with a solvent.
For example, in the Clark Process, a bitumen froth stream comprises bitumen, solids, and water.
Certain processes use naphtha to dilute bitumen froth before separating the product bitumen by centrifugation.
These processes are called naphtha froth treatment (NFT) processes. Other processes use a paraffinic solvent, and are called paraffinic froth treatment (PFT) processes, to produce pipelineable bitumen with low levels of solids and water. In the PFT process, a paraffinic solvent (for example, a mixture of iso-pentane and n-pentane) is used to dilute the froth before separating the product, diluted bitumen, by gravity. A portion of the asphaltenes in the bitumen is also rejected by design in the PFT process and this rejection is used to achieve reduced solids and water levels. In both the NFT and the PFT processes, the diluted tailings (comprising water, solids and some hydrocarbon) are separated from the diluted product bitumen.
Solvent is typically recovered from the diluted product bitumen component before the bitumen is delivered to a refining facility for further processing.
For example, in the Clark Process, a bitumen froth stream comprises bitumen, solids, and water.
Certain processes use naphtha to dilute bitumen froth before separating the product bitumen by centrifugation.
These processes are called naphtha froth treatment (NFT) processes. Other processes use a paraffinic solvent, and are called paraffinic froth treatment (PFT) processes, to produce pipelineable bitumen with low levels of solids and water. In the PFT process, a paraffinic solvent (for example, a mixture of iso-pentane and n-pentane) is used to dilute the froth before separating the product, diluted bitumen, by gravity. A portion of the asphaltenes in the bitumen is also rejected by design in the PFT process and this rejection is used to achieve reduced solids and water levels. In both the NFT and the PFT processes, the diluted tailings (comprising water, solids and some hydrocarbon) are separated from the diluted product bitumen.
Solvent is typically recovered from the diluted product bitumen component before the bitumen is delivered to a refining facility for further processing.
[0009] The PFT process may comprise at least three units: Froth Separation Unit (FSU), Solvent Recovery Unit (SRU) and Tailings Solvent Recovery Unit (TSRU). Mixing of the solvent with the feed bitumen froth may be carried out counter-currently in two stages in separate froth separation units. The bitumen froth comprises bitumen, water, and solids. A
typical composition of bitumen froth is about 60 wt. % bitumen, 30 wt. %
water, and 10 wt. %
solids. The paraffinic solvent is used to dilute the froth before separating the product bitumen by gravity. The foregoing is only an example of a PFT process and the values are provided by way of example only. An example of a PFT process is described in Canadian Patent No.
2,587,166 to Sury.
typical composition of bitumen froth is about 60 wt. % bitumen, 30 wt. %
water, and 10 wt. %
solids. The paraffinic solvent is used to dilute the froth before separating the product bitumen by gravity. The foregoing is only an example of a PFT process and the values are provided by way of example only. An example of a PFT process is described in Canadian Patent No.
2,587,166 to Sury.
[0010] From the PSC, the middlings, which may comprise bitumen and about 10-30 wt.
% solids, or about 20-25 wt. % solids, based on the total wt. % of the middlings, is withdrawn and sent to the flotation cells to further recover bitumen. The middlings are processed by bubbling air through the slurry and creating a bitumen froth, which is recycled back to the PSC.
Flotation tailings (FT) from the flotation cells, comprising mostly solids and water, are sent for further treatment or disposed in an external tailings area (ETA).
[00111 In ETA tailings ponds, a liquid suspension of oil sand fines in water with a solids content greater than 2 wt. %, but less than the solids content corresponding to the Liquid Limit are called Fluid Fine Tailings (FFT). FFT settle over time to produce Mature Fine Tailings (MFT), having above about 30 wt. % solids.
[0012] It would be desirable to have an alternative or improved method of analyzing a slurry stream in an oil sand process.
SUMMARY
[0013] It is an object of the present disclosure to provide a method of analyzing a slurry stream in an oil sand process.
[0014] Disclosed is a method comprising providing a slurry stream comprising bitumen, water, and solids; measuring a natural radiation parameter of the slurry stream; based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream, and based on the estimated FFR, automatically adjusting a process parameter of an oil sand processing plant.
[0015] The foregoing has broadly outlined the features of the present disclosure so that the detailed description that follows may be better understood. Additional features will also be described herein.
BRIEF DESCRIPTION OF TIIE DRAWINGS
[0016] These and other features, aspects and advantages of the disclosure will become apparent from the following description, appending claims and the accompanying drawings, which are briefly described below.
100171 Fig. 1 is a graph illustrating particle size distribution (PSD) of fines fractions of oil sand streams passing through at 325 mesh sieve.
[0018] Fig. 2 is a schematic of PSD in a slurry pipeline.
[0019] Fig. 3 is a graph illustrating Fines to Fluid Ratio (FFR) versus Total Counts per Second (CPS) of a K40 radiation signal.
[0020] Fig. 4 is a flow diagram of a bitumen extraction system with an analyzer.
[0021] Fig. 5 is a flow diagram of analyzer application options on slurry streams in an oil sand processing plant.
[0022] It should be noted that the figures are merely examples and no limitations on the scope of the present disclosure are intended thereby. Further, the figures are generally not drawn to scale, but are drafted for purposes of convenience and clarity in illustrating various aspects of the disclosure.
DETAILED DESCRIPTION
[0023] For the purpose of promoting an understanding of the principles of the disclosure, reference will now be made to the features illustrated in the drawings and specific language will be used to describe the same. It will nevertheless be understood that no limitation of the scope of the disclosure is thereby intended. Any alterations and further modifications, and any further applications of the principles of the disclosure as described herein are contemplated as would normally occur to one skilled in the art to which the disclosure relates. It will be apparent to those skilled in the relevant art that some features that are not relevant to the present disclosure may not be shown in the drawings for the sake of clarity.
[0024] At the outset, for ease of reference, certain terms used in this application and their meaning as used in this context are set forth below. To the extent a term used herein is not defined below, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent.
Further, the present processes are not limited by the usage of the terms shown below, as all equivalents, synonyms, new developments and terms or processes that serve the same or a similar purpose are considered to be within the scope of the present disclosure.
[0025] Throughout this disclosure, where a range is used, any number between or inclusive of the range is implied.
[0026] A "hydrocarbon" is an organic compound that primarily includes the elements of hydrogen and carbon, although nitrogen, sulfur, oxygen, metals, or any number of other elements may be present in small amounts. I Iydrocarbons generally refer to components found in heavy oil or in oil sand. However, the techniques described arc not limited to heavy oils but may also be used with any number of other reservoirs to improve gravity drainage of liquids.
Hydrocarbon compounds may be aliphatic or aromatic, and may be straight chained, branched, or partially or fully cyclic.
[0027] "Bitumen" is a naturally occurring heavy oil material. Generally, it is the hydrocarbon component found in oil sand. Bitumen can vary in composition depending upon the degree of loss of more volatile components. It can vary from a very viscous, tar-like, semi-solid material to solid forms. The hydrocarbon types found in bitumen can include aliphatics, aromatics, resins, and asphaltcnes. A typical bitumen might be composed of:
19 weight (wt.) % aliphatics (which can range from 5 wt. % - 30 wt. %, or higher);
19 wt. % asphaltenes (which can range from 5 wt. % - 30 wt. %, or higher);
30 wt. % aromatics (which can range from 15 wt. % - 50 wt. %, or higher);
32 wt. % resins (which can range from 15 wt. % - 50 wt. %, or higher); and some amount of sulfur (which can range in excess of 7 wt. %), the weight %
based upon total weight of the bitumen.
In addition, bitumen can contain some water and nitrogen compounds ranging from less than 0.4 wt. % to in excess of 0.7 wt. %. The percentage of the hydrocarbon found in bitumen can vary. The term "heavy oil" includes bitumen as well as lighter materials that may be found in a sand or carbonate reservoir.
[0028] "Heavy oil" includes oils which are classified by the American Petroleum Institute ("API"), as heavy oils, extra heavy oils, or bitumens. The term "heavy oil" includes bitumen. Heavy oil may have a viscosity of about 1,000 centipoise (cP) or more, 10,000 cP or more, 100,000 cP or more, or 1,000,000 cP or more. In general, a heavy oil has an API gravity between 22.3 API (density of 920 kilograms per meter cubed (kg/m3) or 0.920 grams per centimeter cubed (g/cm3)) and 10.0 API (density of 1,000 kg/m3 or 1 g/cm3).
An extra heavy oil, in general, has an API gravity of less than 10.0 API (density greater than 1,000 kg/m3 or 1 g/cm3). For example, a source of heavy oil includes oil sand or bituminous sand, which is a combination of clay, sand, water and bitumen.
[0029] "Fine particles" or "fines" are generally defined as those solids having a size of less than 44 microns (jam), as determined by laser diffraction particle size measurement.
[0030] "Coarse particles" are generally defined as those solids having a size of greater than 44 microns (m).
[0031] The term "solvent" as used in the present disclosure should be understood to mean either a single solvent, or a combination of solvents.
[0032] The terms "approximately," "about," "substantially," and similar terms are intended to have a broad meaning in harmony with the common and accepted usage by those of ordinary skill in the art to which the subject matter of this disclosure pertains. It should be understood by those of skill in the art who review this disclosure that these terms are intended to allow a description of certain features described and claimed without restricting the scope of these features to the precise numeral ranges provided. Accordingly, these terms should be interpreted as indicating that insubstantial or inconsequential modifications or alterations of the subject matter described and are considered to be within the scope of the disclosure.
[0033] The articles "the", "a" and "an" are not necessarily limited to mean only one, but rather are inclusive and open ended so as to include, optionally, multiple such elements.
[0034] The term "paraffinic solvent" (also known as aliphatic) as used herein means solvents comprising normal paraffins, isoparaffins or blends thereof in amounts greater than 50 wt. %. Presence of other components such as olefins, aromatics or naphthenes may counteract the function of the paraffinic solvent and hence may be present in an amount of only 1 to 20 wt. % combined, for instance no more than 3 wt. %. The paraffinic solvent may be a C4 to C20 or C4 to C6 paraffinic hydrocarbon solvent or a combination of iso and normal components thereof. The paraffinic solvent may comprise pentane, iso-pentane, or a combination thereof.
The paraffinic solvent may comprise about 60 wt. % pentane and about 40 wt. %
iso-pentane, with 0- 20 wt. % of the counteracting components referred above.
[0035] The process conceived herein is a useful method to analyze a slurry stream comprising bitumen, water, and solids, which may be used for process adjustment. The method may comprise:
a) providing a slurry stream comprising bitumen, water, and solids;
b) measuring a natural radiation parameter of the slurry stream;
c) based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream; and d) based on the estimated FFR, automatically adjusting a process parameter of an oil sand processing plant.
[0036] The fluid is the non-solid portion of the slurry stream and may comprise, or primarily comprise, water and bitumen. In some cases, such as in tailings slurries, the fluid may be predominantly water.
[0037] The process parameter may be any suitable parameter of the processing of the slurry stream. Therefore, a feed-forward process control scheme may be provided that adjusts a process parameter of slurry stream processing in relation to fines content, which may be obtained in real-time, and which may assist in slurry stream processing.
[0038] The method may further comprise, based on the FFR and a fluid mass flow rate of the slurry stream, obtaining a calculated mass fines flow rate in the slurry stream. A flow meter may measure total volumetric flow rate of the slurry stream and a density meter may measure slurry stream density, which together can be mathematically converted to total mass flow rate. Additionally, slurry stream density may also be converted to slurry stream solid content given the known density of the solids, as detailed in the formulas below.
[0039] Step d) may comprise automatically adjusting the process parameter based on the calculated mass fines flow rate in the slurry stream. The method may further comprise, based on the calculated mass fines flow rate in the slurry stream and a solids mass flow rate of the slurry stream, obtaining a calculated mass fines percentage of solids in the slurry stream or a sand-to-fine ratio (SFR) in the slurry stream, wherein step d) comprises automatically adjusting the process parameter based on the calculated fines mass percentage solids in the slurry stream or the SFR in the slurry stream. The solids mass flow rate may be calculated based on total slurry stream flow rate and slurry stream density.
[0040] The slurry stream may be a slip stream taken from a main slurry stream. An analyzer may be installed off a slip stream of a main slurry stream since it may be challenging to achieve installation on a main slurry stream with low attenuation and/or good stabilization due to specific process conditions. For example, for a hydro-transport line in an oil sand plant, direct mounting on the outside of a pipe may not work well because of significant attenuation through steel and significant wall thickness variation as the pipe wears during operation. On the other hand, a slip stream taken off the main stream may afford great flexibility to analyzer installation configurations and shielding that may improve signal strength. By using a slip stream of main slurry stream wherein radio-active components containing fine solid is fully suspended, for instance as opposed to using an analyzer installed over the top of a raw oil sand ore in an apron feeder, a more accurate measurement may be obtained. For the apron feeder installation over the quasi-stagnant raw oil sand ores, due to the attenuation of radiation signals by the solid, the radiation signals may predominantly reflect fines from the surface layer of ore feed, unable to accurately measure the overall fines content of the entire ore body feeding to the ore preparation plant, hydro-transport and then PSC. The result could vary depending on homogeneity of ore in the apron feeder, e.g. the less homogenous the higher degree of inaccuracy. A flowable slurry stream may be operated hydrodynamically to homogenize radio-active components containing fines within the slurry stream to allow a more accurate measurement and robust installation via a slip stream, compared to an installation over an ore body.
[0041] Step c) may comprise obtaining a water mass flow rate of the slurry stream by measuring a volumetric flow rate and a density of the slurry stream.
[0042] The natural radiation parameter is any suitable natural radiation signal or other quantitative indication of radio-active elements contained in the fines in the slurry stream. The natural radiation parameter may be obtained using natural gamma radiation detection. The natural gamma radiation detection may comprise measuring gamma radiation emitted during decay of potassium-40, uranium-238, or thorium-232. Multiple radiation parameters may be measured.
[0043] The natural radiation parameter may be expressed as counts per second as a function of either individual potassium-40, uranium-238, or thorium-232, or as a combined counts per second (CPS) of potassium-40, uranium-238, and thorium-232.
[0044] The natural radiation parameter may be measured using PGNAA (Prompt Gamma Neutron Activation Analysis), LIBS (Laser-Induced Breakdown Spectroscopy), reflectance Hyperspectroscopy, or XRF (X-Ray Fluorescence).
[0045] The natural radiation parameter may be a total natural radiation signal measured across an entire spectrum. This is discussed below with reference to Fig. 3.
[0046] The slurry stream may be any suitable flowable slurry stream comprising bitumen, water, and solids. The slurry stream may be a feed stream to a primary separation cell (PSC), bitumen froth, middlings, coarse sand tailings (CST), flotation tailings, thickener feed, thickener overflow, thickener underflow, recycle fluid fine tailings (FFT) or mature fine tailings (MFT) from a tailings pond, tailings solvent recovery unit (TSRU) tailings, or a slurry from a paraffinic froth treatment (PFT) (or product cleaning) section which contains fine bearing radio-active components.
[0047] The process parameter may be process aid addition, ore feed rate, ore blending, temperature, dilution water addition, middlings withdrawal rate, flotation cell bypass, flocculant addition, fluid fine tailings (FFT) blending ratio, thickener bed height operation, by-pass rate of flotation tailings (FT), underflow rate, or second stage dilution.
[00481 Steps a) to c) may be effected continuously. Step b) may be effected online, inline, offline, or atline.
[0049] Consistent with the foregoing, compositional analysis of a slurry stream may assist in achieving an accurate and useful real-time fines measurement for oil sand streams, which may improve process control. This measurement may be performed by any suitable instrument or technique capable of providing the relevant data with acceptable precision to indicate fines or clay flow rate in conjunction with instrumentation such as a density meter to provide the FFR of the slurry stream.
[0050] In the oil sand industry, fines are defined as particles passing through 325 mesh sieve (44tm opening). As shown in Fig. 1, a typical fines fraction separated out using a 44tm sieve has a D50 of less than 10 m and a D90 of less than 331,tm. In the slurry processing industry, these fines particles are regarded as part of the carrier fluid together with water due to their non-settling behavior during most flow conditions. As illustrated in Fig. 2, a slurry slip stream (202) and a main slurry stream (204) share the same carrier fluid, or fluid primarily comprising water and bitumen, and fines, thus the same Fines to Fluid Ratio (FFR). An analyzer (206) may be installed on the slurry slip stream (202) to detect the radiation signals from fines in the carrier fluid. Rather than using a single K40 count, a K40 total radiation signal may be used using a total counts per second (CPS) by integration of the entire spectrum. As shown in Fig. 3, a linear correlation was found between total CPS and FFR of different types of slurry streams that can found in oil sand plants (referred to in Fig. 3 as Slurry #1 and Slurry #2). In Fig. 3, the error bar denotes two times standard deviation (2X STD). As shown in Fig. 3, the standard deviation of total CPS was low and much lower than that of K40 CPS
(data not shown), making it potentially more reliable in measuring fines in a slurry stream.
[0051] The correlation between FFR and total CPS of a K40 analyzer in a slurry stream allows the fines flowrate to be determined via a radiation analyzer and the water flow rate that is determined via a volumetric flow meter and a densitometer in the main pipeline. This is shown in the following equations.
% solids, or about 20-25 wt. % solids, based on the total wt. % of the middlings, is withdrawn and sent to the flotation cells to further recover bitumen. The middlings are processed by bubbling air through the slurry and creating a bitumen froth, which is recycled back to the PSC.
Flotation tailings (FT) from the flotation cells, comprising mostly solids and water, are sent for further treatment or disposed in an external tailings area (ETA).
[00111 In ETA tailings ponds, a liquid suspension of oil sand fines in water with a solids content greater than 2 wt. %, but less than the solids content corresponding to the Liquid Limit are called Fluid Fine Tailings (FFT). FFT settle over time to produce Mature Fine Tailings (MFT), having above about 30 wt. % solids.
[0012] It would be desirable to have an alternative or improved method of analyzing a slurry stream in an oil sand process.
SUMMARY
[0013] It is an object of the present disclosure to provide a method of analyzing a slurry stream in an oil sand process.
[0014] Disclosed is a method comprising providing a slurry stream comprising bitumen, water, and solids; measuring a natural radiation parameter of the slurry stream; based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream, and based on the estimated FFR, automatically adjusting a process parameter of an oil sand processing plant.
[0015] The foregoing has broadly outlined the features of the present disclosure so that the detailed description that follows may be better understood. Additional features will also be described herein.
BRIEF DESCRIPTION OF TIIE DRAWINGS
[0016] These and other features, aspects and advantages of the disclosure will become apparent from the following description, appending claims and the accompanying drawings, which are briefly described below.
100171 Fig. 1 is a graph illustrating particle size distribution (PSD) of fines fractions of oil sand streams passing through at 325 mesh sieve.
[0018] Fig. 2 is a schematic of PSD in a slurry pipeline.
[0019] Fig. 3 is a graph illustrating Fines to Fluid Ratio (FFR) versus Total Counts per Second (CPS) of a K40 radiation signal.
[0020] Fig. 4 is a flow diagram of a bitumen extraction system with an analyzer.
[0021] Fig. 5 is a flow diagram of analyzer application options on slurry streams in an oil sand processing plant.
[0022] It should be noted that the figures are merely examples and no limitations on the scope of the present disclosure are intended thereby. Further, the figures are generally not drawn to scale, but are drafted for purposes of convenience and clarity in illustrating various aspects of the disclosure.
DETAILED DESCRIPTION
[0023] For the purpose of promoting an understanding of the principles of the disclosure, reference will now be made to the features illustrated in the drawings and specific language will be used to describe the same. It will nevertheless be understood that no limitation of the scope of the disclosure is thereby intended. Any alterations and further modifications, and any further applications of the principles of the disclosure as described herein are contemplated as would normally occur to one skilled in the art to which the disclosure relates. It will be apparent to those skilled in the relevant art that some features that are not relevant to the present disclosure may not be shown in the drawings for the sake of clarity.
[0024] At the outset, for ease of reference, certain terms used in this application and their meaning as used in this context are set forth below. To the extent a term used herein is not defined below, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent.
Further, the present processes are not limited by the usage of the terms shown below, as all equivalents, synonyms, new developments and terms or processes that serve the same or a similar purpose are considered to be within the scope of the present disclosure.
[0025] Throughout this disclosure, where a range is used, any number between or inclusive of the range is implied.
[0026] A "hydrocarbon" is an organic compound that primarily includes the elements of hydrogen and carbon, although nitrogen, sulfur, oxygen, metals, or any number of other elements may be present in small amounts. I Iydrocarbons generally refer to components found in heavy oil or in oil sand. However, the techniques described arc not limited to heavy oils but may also be used with any number of other reservoirs to improve gravity drainage of liquids.
Hydrocarbon compounds may be aliphatic or aromatic, and may be straight chained, branched, or partially or fully cyclic.
[0027] "Bitumen" is a naturally occurring heavy oil material. Generally, it is the hydrocarbon component found in oil sand. Bitumen can vary in composition depending upon the degree of loss of more volatile components. It can vary from a very viscous, tar-like, semi-solid material to solid forms. The hydrocarbon types found in bitumen can include aliphatics, aromatics, resins, and asphaltcnes. A typical bitumen might be composed of:
19 weight (wt.) % aliphatics (which can range from 5 wt. % - 30 wt. %, or higher);
19 wt. % asphaltenes (which can range from 5 wt. % - 30 wt. %, or higher);
30 wt. % aromatics (which can range from 15 wt. % - 50 wt. %, or higher);
32 wt. % resins (which can range from 15 wt. % - 50 wt. %, or higher); and some amount of sulfur (which can range in excess of 7 wt. %), the weight %
based upon total weight of the bitumen.
In addition, bitumen can contain some water and nitrogen compounds ranging from less than 0.4 wt. % to in excess of 0.7 wt. %. The percentage of the hydrocarbon found in bitumen can vary. The term "heavy oil" includes bitumen as well as lighter materials that may be found in a sand or carbonate reservoir.
[0028] "Heavy oil" includes oils which are classified by the American Petroleum Institute ("API"), as heavy oils, extra heavy oils, or bitumens. The term "heavy oil" includes bitumen. Heavy oil may have a viscosity of about 1,000 centipoise (cP) or more, 10,000 cP or more, 100,000 cP or more, or 1,000,000 cP or more. In general, a heavy oil has an API gravity between 22.3 API (density of 920 kilograms per meter cubed (kg/m3) or 0.920 grams per centimeter cubed (g/cm3)) and 10.0 API (density of 1,000 kg/m3 or 1 g/cm3).
An extra heavy oil, in general, has an API gravity of less than 10.0 API (density greater than 1,000 kg/m3 or 1 g/cm3). For example, a source of heavy oil includes oil sand or bituminous sand, which is a combination of clay, sand, water and bitumen.
[0029] "Fine particles" or "fines" are generally defined as those solids having a size of less than 44 microns (jam), as determined by laser diffraction particle size measurement.
[0030] "Coarse particles" are generally defined as those solids having a size of greater than 44 microns (m).
[0031] The term "solvent" as used in the present disclosure should be understood to mean either a single solvent, or a combination of solvents.
[0032] The terms "approximately," "about," "substantially," and similar terms are intended to have a broad meaning in harmony with the common and accepted usage by those of ordinary skill in the art to which the subject matter of this disclosure pertains. It should be understood by those of skill in the art who review this disclosure that these terms are intended to allow a description of certain features described and claimed without restricting the scope of these features to the precise numeral ranges provided. Accordingly, these terms should be interpreted as indicating that insubstantial or inconsequential modifications or alterations of the subject matter described and are considered to be within the scope of the disclosure.
[0033] The articles "the", "a" and "an" are not necessarily limited to mean only one, but rather are inclusive and open ended so as to include, optionally, multiple such elements.
[0034] The term "paraffinic solvent" (also known as aliphatic) as used herein means solvents comprising normal paraffins, isoparaffins or blends thereof in amounts greater than 50 wt. %. Presence of other components such as olefins, aromatics or naphthenes may counteract the function of the paraffinic solvent and hence may be present in an amount of only 1 to 20 wt. % combined, for instance no more than 3 wt. %. The paraffinic solvent may be a C4 to C20 or C4 to C6 paraffinic hydrocarbon solvent or a combination of iso and normal components thereof. The paraffinic solvent may comprise pentane, iso-pentane, or a combination thereof.
The paraffinic solvent may comprise about 60 wt. % pentane and about 40 wt. %
iso-pentane, with 0- 20 wt. % of the counteracting components referred above.
[0035] The process conceived herein is a useful method to analyze a slurry stream comprising bitumen, water, and solids, which may be used for process adjustment. The method may comprise:
a) providing a slurry stream comprising bitumen, water, and solids;
b) measuring a natural radiation parameter of the slurry stream;
c) based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream; and d) based on the estimated FFR, automatically adjusting a process parameter of an oil sand processing plant.
[0036] The fluid is the non-solid portion of the slurry stream and may comprise, or primarily comprise, water and bitumen. In some cases, such as in tailings slurries, the fluid may be predominantly water.
[0037] The process parameter may be any suitable parameter of the processing of the slurry stream. Therefore, a feed-forward process control scheme may be provided that adjusts a process parameter of slurry stream processing in relation to fines content, which may be obtained in real-time, and which may assist in slurry stream processing.
[0038] The method may further comprise, based on the FFR and a fluid mass flow rate of the slurry stream, obtaining a calculated mass fines flow rate in the slurry stream. A flow meter may measure total volumetric flow rate of the slurry stream and a density meter may measure slurry stream density, which together can be mathematically converted to total mass flow rate. Additionally, slurry stream density may also be converted to slurry stream solid content given the known density of the solids, as detailed in the formulas below.
[0039] Step d) may comprise automatically adjusting the process parameter based on the calculated mass fines flow rate in the slurry stream. The method may further comprise, based on the calculated mass fines flow rate in the slurry stream and a solids mass flow rate of the slurry stream, obtaining a calculated mass fines percentage of solids in the slurry stream or a sand-to-fine ratio (SFR) in the slurry stream, wherein step d) comprises automatically adjusting the process parameter based on the calculated fines mass percentage solids in the slurry stream or the SFR in the slurry stream. The solids mass flow rate may be calculated based on total slurry stream flow rate and slurry stream density.
[0040] The slurry stream may be a slip stream taken from a main slurry stream. An analyzer may be installed off a slip stream of a main slurry stream since it may be challenging to achieve installation on a main slurry stream with low attenuation and/or good stabilization due to specific process conditions. For example, for a hydro-transport line in an oil sand plant, direct mounting on the outside of a pipe may not work well because of significant attenuation through steel and significant wall thickness variation as the pipe wears during operation. On the other hand, a slip stream taken off the main stream may afford great flexibility to analyzer installation configurations and shielding that may improve signal strength. By using a slip stream of main slurry stream wherein radio-active components containing fine solid is fully suspended, for instance as opposed to using an analyzer installed over the top of a raw oil sand ore in an apron feeder, a more accurate measurement may be obtained. For the apron feeder installation over the quasi-stagnant raw oil sand ores, due to the attenuation of radiation signals by the solid, the radiation signals may predominantly reflect fines from the surface layer of ore feed, unable to accurately measure the overall fines content of the entire ore body feeding to the ore preparation plant, hydro-transport and then PSC. The result could vary depending on homogeneity of ore in the apron feeder, e.g. the less homogenous the higher degree of inaccuracy. A flowable slurry stream may be operated hydrodynamically to homogenize radio-active components containing fines within the slurry stream to allow a more accurate measurement and robust installation via a slip stream, compared to an installation over an ore body.
[0041] Step c) may comprise obtaining a water mass flow rate of the slurry stream by measuring a volumetric flow rate and a density of the slurry stream.
[0042] The natural radiation parameter is any suitable natural radiation signal or other quantitative indication of radio-active elements contained in the fines in the slurry stream. The natural radiation parameter may be obtained using natural gamma radiation detection. The natural gamma radiation detection may comprise measuring gamma radiation emitted during decay of potassium-40, uranium-238, or thorium-232. Multiple radiation parameters may be measured.
[0043] The natural radiation parameter may be expressed as counts per second as a function of either individual potassium-40, uranium-238, or thorium-232, or as a combined counts per second (CPS) of potassium-40, uranium-238, and thorium-232.
[0044] The natural radiation parameter may be measured using PGNAA (Prompt Gamma Neutron Activation Analysis), LIBS (Laser-Induced Breakdown Spectroscopy), reflectance Hyperspectroscopy, or XRF (X-Ray Fluorescence).
[0045] The natural radiation parameter may be a total natural radiation signal measured across an entire spectrum. This is discussed below with reference to Fig. 3.
[0046] The slurry stream may be any suitable flowable slurry stream comprising bitumen, water, and solids. The slurry stream may be a feed stream to a primary separation cell (PSC), bitumen froth, middlings, coarse sand tailings (CST), flotation tailings, thickener feed, thickener overflow, thickener underflow, recycle fluid fine tailings (FFT) or mature fine tailings (MFT) from a tailings pond, tailings solvent recovery unit (TSRU) tailings, or a slurry from a paraffinic froth treatment (PFT) (or product cleaning) section which contains fine bearing radio-active components.
[0047] The process parameter may be process aid addition, ore feed rate, ore blending, temperature, dilution water addition, middlings withdrawal rate, flotation cell bypass, flocculant addition, fluid fine tailings (FFT) blending ratio, thickener bed height operation, by-pass rate of flotation tailings (FT), underflow rate, or second stage dilution.
[00481 Steps a) to c) may be effected continuously. Step b) may be effected online, inline, offline, or atline.
[0049] Consistent with the foregoing, compositional analysis of a slurry stream may assist in achieving an accurate and useful real-time fines measurement for oil sand streams, which may improve process control. This measurement may be performed by any suitable instrument or technique capable of providing the relevant data with acceptable precision to indicate fines or clay flow rate in conjunction with instrumentation such as a density meter to provide the FFR of the slurry stream.
[0050] In the oil sand industry, fines are defined as particles passing through 325 mesh sieve (44tm opening). As shown in Fig. 1, a typical fines fraction separated out using a 44tm sieve has a D50 of less than 10 m and a D90 of less than 331,tm. In the slurry processing industry, these fines particles are regarded as part of the carrier fluid together with water due to their non-settling behavior during most flow conditions. As illustrated in Fig. 2, a slurry slip stream (202) and a main slurry stream (204) share the same carrier fluid, or fluid primarily comprising water and bitumen, and fines, thus the same Fines to Fluid Ratio (FFR). An analyzer (206) may be installed on the slurry slip stream (202) to detect the radiation signals from fines in the carrier fluid. Rather than using a single K40 count, a K40 total radiation signal may be used using a total counts per second (CPS) by integration of the entire spectrum. As shown in Fig. 3, a linear correlation was found between total CPS and FFR of different types of slurry streams that can found in oil sand plants (referred to in Fig. 3 as Slurry #1 and Slurry #2). In Fig. 3, the error bar denotes two times standard deviation (2X STD). As shown in Fig. 3, the standard deviation of total CPS was low and much lower than that of K40 CPS
(data not shown), making it potentially more reliable in measuring fines in a slurry stream.
[0051] The correlation between FFR and total CPS of a K40 analyzer in a slurry stream allows the fines flowrate to be determined via a radiation analyzer and the water flow rate that is determined via a volumetric flow meter and a densitometer in the main pipeline. This is shown in the following equations.
-11-[0052] (1) Fines Mass Flow main= FFR main x Fluid Mass Flow main [0053] (2) FFRsiii, = ITRmain -= FFR
[0054] (3) Fluid Mass Flowmam = Slurry Mass Flowmain ¨ Solid Mass Flowmain [0055] (4) FFRsiip = f (Total CPS) = (a x Total CPS ¨ 13) [0056] (5) Fines Mass Flow main = FFRshp x Fluid Mass Flowmain [0057] (6) Fines Mass Flowmain = f (Total CPS) x Fluid Mass Flowmain = (a x Total CPS
- 13) x Fluid Mass Flow main [0058] FFRmain is the FFR (fines-to-fluid mass ratio) in the main stream.
[0059] FFRsiip is the FFR (fines-to-fluid mass ratio) in the slip stream.
[0060] Fluid Mass Flow is the Mass flow rate of non-solid fluids which may comprise, or primarily comprise, water and bitumen.
[0061] a and 13, are constants determined from a correlation between FFR
and radiation signals.
[0062] The unit for mass flow rate is not limited and may be, for example, tonne/hr or MT/hr (metric ton / hr).
[0063] While a linear correlation may occur such as in Fig. 3, another type of function may alternatively be found and used. Additionally, while total CPS may be used as the signal, other radiation signals may be used as well as described herein.
[0064] Table 1 summarizes estimated measurement resolutions on FFR and Fines Flow using the proposed approach.
[0054] (3) Fluid Mass Flowmam = Slurry Mass Flowmain ¨ Solid Mass Flowmain [0055] (4) FFRsiip = f (Total CPS) = (a x Total CPS ¨ 13) [0056] (5) Fines Mass Flow main = FFRshp x Fluid Mass Flowmain [0057] (6) Fines Mass Flowmain = f (Total CPS) x Fluid Mass Flowmain = (a x Total CPS
- 13) x Fluid Mass Flow main [0058] FFRmain is the FFR (fines-to-fluid mass ratio) in the main stream.
[0059] FFRsiip is the FFR (fines-to-fluid mass ratio) in the slip stream.
[0060] Fluid Mass Flow is the Mass flow rate of non-solid fluids which may comprise, or primarily comprise, water and bitumen.
[0061] a and 13, are constants determined from a correlation between FFR
and radiation signals.
[0062] The unit for mass flow rate is not limited and may be, for example, tonne/hr or MT/hr (metric ton / hr).
[0063] While a linear correlation may occur such as in Fig. 3, another type of function may alternatively be found and used. Additionally, while total CPS may be used as the signal, other radiation signals may be used as well as described herein.
[0064] Table 1 summarizes estimated measurement resolutions on FFR and Fines Flow using the proposed approach.
- 12 -[0065] Table 1. Estimation on FFR and Fines Flow Measurement Resolution Hydro- MD ¨ middlings Coarse Sand Flotation tranport line taken from Tailings (CST) Tailings (FT) middle of PSC
Mean FFR 0.073 0.071 0.082 0.075 FFR resolution 0.002 0.002 0.002 0.002 using total CPS
Relative FFR 2% 3% 2% 2%
resolution using total CPS
Nominal Fine 6 MT/h (Nominal 10,000 ore feed and 8,400 T/h solid feed) Flow Resolution for hydro-transport line [0066] Fig. 4 shows an example of a bitumen extraction system showing the use of an analyzer. A similar scheme may be applied to other slurry streams in an oil sand plant to allow accurate fines flow measurement in real-time to provide important process information for process adjustments and/or to track fines flows and balance throughout the plant. Fig. 4 illustrates a hydro-transport line (402) feeding a slurry stream into a PSC
(404). A radiation analyzer (406) analyzes the slurry stream. Middlings (408a, 408b, and 408c) pass from the PSC
(404) to flotation cells (410), through a flotation pump box (412) to a tailings pond or downstream process unit(s) (not shown). Coarse sand tailings (420) exit the PSC (404) for delivery to a tailings pond or downstream processing unit(s) (not shown).
[0067] Fig. 5 is a flow diagram illustrating certain radiation analyzer application options on a slurry stream in an oil sand processing plant. Fig. 5 illustrates a hydro-transport line (502) feeding a slurry stream into a PSC (504). Three streams are withdrawn from the PSC (504), namely bitumen froth (506), middlings (508), and coarse sand tailings (CST) (510). The middlings (508) may be sent to flotation cells (512) and to a thickener (514) producing an overflow (516) and an underflow (518) which is passed to a pump (520) and then to a mixer (522) and deposited as tailings (524). Some tailings (526) may be recycled back to the thickener (514). Analyzers (shown as 528a, 528b, 528c, 528d, 528e, 528f, and 528g) may be placed in various streams in the process of the oil sand processing plant.
Mean FFR 0.073 0.071 0.082 0.075 FFR resolution 0.002 0.002 0.002 0.002 using total CPS
Relative FFR 2% 3% 2% 2%
resolution using total CPS
Nominal Fine 6 MT/h (Nominal 10,000 ore feed and 8,400 T/h solid feed) Flow Resolution for hydro-transport line [0066] Fig. 4 shows an example of a bitumen extraction system showing the use of an analyzer. A similar scheme may be applied to other slurry streams in an oil sand plant to allow accurate fines flow measurement in real-time to provide important process information for process adjustments and/or to track fines flows and balance throughout the plant. Fig. 4 illustrates a hydro-transport line (402) feeding a slurry stream into a PSC
(404). A radiation analyzer (406) analyzes the slurry stream. Middlings (408a, 408b, and 408c) pass from the PSC
(404) to flotation cells (410), through a flotation pump box (412) to a tailings pond or downstream process unit(s) (not shown). Coarse sand tailings (420) exit the PSC (404) for delivery to a tailings pond or downstream processing unit(s) (not shown).
[0067] Fig. 5 is a flow diagram illustrating certain radiation analyzer application options on a slurry stream in an oil sand processing plant. Fig. 5 illustrates a hydro-transport line (502) feeding a slurry stream into a PSC (504). Three streams are withdrawn from the PSC (504), namely bitumen froth (506), middlings (508), and coarse sand tailings (CST) (510). The middlings (508) may be sent to flotation cells (512) and to a thickener (514) producing an overflow (516) and an underflow (518) which is passed to a pump (520) and then to a mixer (522) and deposited as tailings (524). Some tailings (526) may be recycled back to the thickener (514). Analyzers (shown as 528a, 528b, 528c, 528d, 528e, 528f, and 528g) may be placed in various streams in the process of the oil sand processing plant.
- 13 -[0068] It should be understood that numerous changes, modifications, and alternatives to the preceding disclosure can be made without departing from the scope of the disclosure.
The preceding description, therefore, is not meant to limit the scope of the disclosure. Rather, the scope of the disclosure is to be determined only by the appended claims and their equivalents. It is also contemplated that structures and features in the present examples can be altered, rearranged, substituted, deleted, duplicated, combined, or added to each other.
The preceding description, therefore, is not meant to limit the scope of the disclosure. Rather, the scope of the disclosure is to be determined only by the appended claims and their equivalents. It is also contemplated that structures and features in the present examples can be altered, rearranged, substituted, deleted, duplicated, combined, or added to each other.
- 14 -
Claims (14)
1. A method comprising:
a) providing a slurry stream comprising bitumen, water, and solids;
b) measuring a natural radiation parameter of the slurry stream;
c) obtaining a fluid mass flow rate of the slurry stream by measuring a volumetric flow rate and a density of the slurry stream;
d) based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream;
e) based on the FFR and the fluid mass flow rate of the slurry stream, obtaining a calculated mass fines flow rate in the slurry stream;
f) obtaining a calculated fines mass percentage of solids in the slurry stream or a sand-to-fine ratio (SFR) in the slurry stream, based on the calculated mass fines flow rate in the slurry stream and a solids mass flow rate of the slurry stream;
and g) automatically adjusting a process parameter of an oils sand processing plant based on the calculated fines mass percentage solids in the slurry stream or the SFR in the slurry stream.
a) providing a slurry stream comprising bitumen, water, and solids;
b) measuring a natural radiation parameter of the slurry stream;
c) obtaining a fluid mass flow rate of the slurry stream by measuring a volumetric flow rate and a density of the slurry stream;
d) based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream;
e) based on the FFR and the fluid mass flow rate of the slurry stream, obtaining a calculated mass fines flow rate in the slurry stream;
f) obtaining a calculated fines mass percentage of solids in the slurry stream or a sand-to-fine ratio (SFR) in the slurry stream, based on the calculated mass fines flow rate in the slurry stream and a solids mass flow rate of the slurry stream;
and g) automatically adjusting a process parameter of an oils sand processing plant based on the calculated fines mass percentage solids in the slurry stream or the SFR in the slurry stream.
2. The method of claim 1, wherein step e) comprises automatically adjusting the process parameter based on the calculated mass fines flow rate in the slurry stream.
3. The method of claim 1, wherein step e) comprises automatically adjusting the process parameter based on the SFR in the slurry stream
4. The method of any one of claims 1 to 3, wherein the slurry stream is a slip stream taken from a main slurry stream.
5. The method of claim 4, wherein step d) comprises obtaining a water mass flow rate of the slurry stream by measuring a volumetric flow rate and a density of the slurry stream.
6. The method of any one of claims 1 to 5, wherein the natural radiation parameter is obtained using natural gamma radiation detection.
7. The method of claim 6, wherein the natural gamma radiation detection comprises measuring gamma radiation emitted during decay of potassium-40, uranium-238, or thorium-232.
8. The method of any one of claims 1 to 7, wherein the natural radiation parameter is expressed as counts per second as a function of either individual potassium-40, uranium-238, or thorium-232, or as a combined counts per second (CPS) of potassium-40, uranium-238, and thorium-232.
9. The method of any one of claims 1 to 8, wherein the natural radiation parameter is measured using PGNAA (Prompt Gamma Neutron Activation Analysis), LIBS (Laser-Induced BreakdownSpectroscopy), reflectance Hyperspectroscopy, or XRF (X-Ray Fluorescence).
10. The method of any one of claims 1 to 9, wherein the natural radiation parameter is a total natural radiation signal measured across an entire spectrum.
11. The method of any one of claims 1 to 10, wherein the slurry stream is a feed stream to a primary separation cell (PSC), bitumen froth, middlings, coarse sand tailings (CST), flotation tailings, thickener feed, thickener overflow, thickener underflow, recycle fluid fine tailings (FFT) or mature fine tailings (MFT) from a tailings pond, tailings solvent recovery unit (TSRU) tailings, or a slurry from a paraffinic froth treatment (PFT) product cleaning.
12. The method of claim 11, wherein the process parameter comprises process aid addition, ore feed rate, ore blending, temperature, dilution water addition, middlings withdrawal rate, flotation cell bypass, flocculant addition, fluid fine tailings (FFT) blending ratio, thickener bed height operation, by-pass rate of flotation tailings (FT), underflow rate, or second stage dilution.
13. The method of any one of claims 1 to 12, wherein steps a) to d) are effected continuously.
14. The method of any one of claims 1 to 13, wherein step b) is effected online, inline, offline, or atline.
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| CA2952398A CA2952398C (en) | 2016-12-21 | 2016-12-21 | Analyzing oil sand streams |
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| DE102019109051A1 (en) * | 2019-04-05 | 2020-10-08 | Rwe Power Ag | Devices and methods for determining an elemental composition of a material |
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| US10371633B2 (en) | 2017-10-30 | 2019-08-06 | Saudi Arabian Oil Company | Determining a specific gravity of a sample |
| US11662288B2 (en) | 2020-09-24 | 2023-05-30 | Saudi Arabian Oil Company | Method for measuring API gravity of petroleum crude oils using angle-resolved fluorescence spectra |
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